IR 05000261/2009004

IR 05000261-09-004, on July 1, 2009 - September 30, 2009, H.B. Robinson Steam Electric Plant - NRC Integrated Inspection Report

ML093020685
Person / Time
Site:	Robinson
Issue date:	10/29/2009
From:	Randy Musser NRC/RGN-II/DRP/RPB4
To:	Mccartney E Carolina Power & Light Co
References
IR-09-004
Download: ML093020685 (23)

Text

UNITED STATES NUCLEAR REGULATORY COMMISSION ber 29, 2009

SUBJECT:

H.B. ROBINSON STEAM ELECTRIC PLANT - NRC INTEGRATED INSPECTION REPORT 05000261/2009004

Dear Mr. McCartney:

On September 30, 2009, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at your H.B. Robinson reactor facility. The enclosed integrated inspection report documents the inspection findings, which were discussed on October 15, 2009, with Mr. Keith Jensen and other members of your staff.

The inspection examined activities conducted under your license as they relate to safety and compliance with the Commissions rules and regulations and with the conditions of your license.

The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel.

Based on the results of this inspection, no findings of significance were identified.

In accordance with 10 CFR 2.390 of the NRC's "Rules of Practice," a copy of this letter and its enclosure will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records (PARS) component of NRC's document system (ADAMS). ADAMS is accessible from the NRC Web site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).

Sincerely,

/RA/

Randall A. Musser, Chief Reactor Projects Branch 4 Division of Reactor Projects Docket No.: 50-261 License No.: DPR-23

Enclosure:

Inspection Report 05000261/2009004 w/Attachment: Supplemental Information

REGION II==

Docket No: 50-261 License No: DPR-23 Report No: 005000261/2009004 Facility: H. B. Robinson Steam Electric Plant, Unit 2 Location: 3581 West Entrance Road Hartsville, SC 29550 Dates: July 1, 2009 - September 30, 2009 Inspectors: J. Hickey, Senior Resident Inspector E. Morris, Resident Inspector J. Zeiler, Senior Resident Inspector, Summer B. Hagar, Senior Project Engineer, Region IV S. Stewart, Senior Resident Inspector, Turkey Point M. Barillas, Resident Inspector, Turkey Point Approved by: R. Musser, Chief Reactor Projects Branch 4 Division of Reactor Projects Enclosure

SUMMARY OF FINDINGS

IR 05000261/2009004, 07/01/2009 - 09/30/2009; H.B. Robinson Steam Electric Plant, Unit 2;

Routine Integrated Report.

The report covered a three month period of inspection by resident inspectors and a senior project engineer. No findings were identified during this inspection period.

NRC-Identified and Self-Revealing Findings

None

Licensee-Identified Violations

None

REPORT DETAILS

Summary of Plant Status

The unit began the inspection period at rated thermal power, and operated at full power for the entire inspection period.

REACTOR SAFETY

Cornerstones: Initiating Events, Mitigating Systems, Barrier Integrity

1R04 Equipment Alignment

a. Inspection Scope

Partial System Walkdowns:

The inspectors performed the following three partial system walkdowns, while the indicated structures, systems, and/or components (SSCs) were out-of-service for maintenance and testing:

System Walked Down SSC Out of Service Date Inspected A emergency diesel generator B emergency diesel generator July 13 A and B charging pumps C charging pump August 21 A and steam driven auxiliary B auxiliary feedwater pump September 8 feedwater pump trains To evaluate the operability of the selected trains or systems under these conditions, the inspectors compared observed positions of valves, switches, and electrical power breakers to the procedures and drawings listed in the Attachment.

Complete System Walkdown:

This inspection sample was completed using the guidance listed in Operating Experience Smart Sample: OpESS FY2009-02, Negative Trend and Recurring Events Involving Feedwater Systems. The inspectors conducted a detailed review of the alignment and condition of the auxiliary feedwater system to verify that the existing alignment of the system was consistent with the correct alignment. To determine the correct system alignment, the inspectors reviewed the procedures, drawings, and the Updated Final Safety Analysis Report (UFSAR). The inspectors also walked down the system. During the walkdown, the inspectors reviewed the following:

• Valves were correctly positioned and did not exhibit leakage that would impact the functions of any given valve.

• Electrical power was available as required.

• Major system components were correctly labeled, lubricated, cooled, ventilated, etc

• Hangers and supports were correctly installed and functional.* Essential support systems were operational.

• Ancillary equipment or debris did not interfere with system performance.

• Tagging clearances were appropriate.

• Valves were locked as required by the locked valve program.

• Breakers were correctly positioned.

• Electrical power was available as required.

• Major system components were correctly labeled.

• Cabinets, cable trays, and conduits were correctly installed and functional.

• Visible cabling appeared to be in good material condition.

• Essential support systems were operational.

• Ancillary equipment or debris did not interfere with system performance.

• Tagging clearances were appropriate.

The inspectors reviewed the documents listed in the Attachment to verify that the ability of the system to perform its functions could not be affected by outstanding design issues, temporary modifications, operator workarounds, adverse conditions, and other system-related issues tracked by the engineering department.

The inspectors reviewed the following action requests (ARs) associated with this area to verify that the licensee identified and implemented appropriate corrective actions:

• 260817, [Water Cooled Condensing Unit]-1B flow control valve not controlling service water flow properly; and

• 274879, unlabeled valve identified in the motor driven auxiliary feedwater pump room

b. Findings

No findings of significance were identified.

1R05 Fire Protection

a. Inspection Scope

For the six areas identified below, the inspectors reviewed the control of transient combustible material and ignition sources, fire detection and suppression capabilities, fire barriers, and any related compensatory measures to verify that those items were consistent with UFSAR Section 9.5.1, Fire Protection System, and UFSAR Appendix 9.5.A, Fire Hazards

Analysis.

The inspectors walked down accessible portions of each area and reviewed results from related surveillance tests to verify that conditions in these areas were consistent with descriptions of the areas in the UFSAR. Documents reviewed are listed in the Attachment.

The following areas were inspected:

Fire Zone Description A emergency diesel generator room battery room control room 25D Dedicated Shutdown Emergency Diesel Generator 25F Turbine Building West Mezzanine 25G Turbine Building Operating Floor The inspectors reviewed the following ARs associated with this area to verify that the licensee identified and implemented appropriate corrective actions:

• 294165, Failure to Track Four Bagged Fire Detectors

• 299115, Unattended Cardboard Box in Rod Drive Room

b. Findings

No findings of significance were identified.

1R06 Flood Protection Measures

a. Inspection Scope

Because the B emergency diesel generator room and safety injection pump room contains risk-significant SSCs which are susceptible to internal flooding from postulated pipe breaks, the inspectors walked down these two rooms to verify that the area configuration, features, and equipment functions were consistent with the descriptions and assumptions used in Calculation RNP-F/PSA-0009, Assessment of Internally Initiated Flooding Events, and in the supporting basis documents listed in the

. The inspectors reviewed the operator actions credited in the analysis to verify that the desired results could be achieved using the plant procedures listed in the

b. Findings

No findings of significance were identified.

1R11 Licensed Operator Requalification

a. Inspection Scope

The inspectors observed licensed-operator performance during requalification simulator training for crew five to verify that operator performance was consistent with expected operator performance, as described in Licensed Operator Continuing Training scenario LOCT-03-1 Rev 4. This training tested the operators ability to operate components from the control room, direct auxiliary operator actions, and determine the appropriate emergency action level classifications while responding to a fire in MCC-6 and subsequent loss of all component cooling water. The inspectors focused on clarity and formality of communication, the use of procedures, alarm response, control board manipulations, group dynamics, and supervisory oversight.

The inspectors observed the post-exercise critique to verify that the licensee identified deficiencies and discrepancies that occurred during the simulator training.

The inspectors reviewed the following ARs associated with this area to verify that the licensee identified and implemented appropriate corrective actions:

• 288393, Exam original left on copy machine unattended to for 15 minutes

• 288897, Weekly exam content compare to covered material

b. Findings

No findings of significance were identified.

1R12 Maintenance Effectiveness

a. Inspection Scope

The inspectors reviewed the two degraded SSC/function performance problems or conditions listed below to verify that the licensee appropriately handled them in accordance with 10 CFR 50, Appendix B, Criterion XVI, Corrective Action, and 10 CFR 50.65, Maintenance Rule. Documents reviewed are listed in the Attachment.

The problem/condition and the corresponding ARs were:

Performance Problem/Condition AR B containment spray pump exhibited binding when rotated by hand 302718 RC-551B pressurizer safety accelerometer failed low 345703 During the reviews, the inspectors focused on the following:

• Appropriate work practices,

• Identifying and addressing common cause failures,

• Scoping in accordance with 10 CFR 50.65(b),

• Characterizing reliability issues (performance),

• Charging unavailability (performance),

• Trending key parameters (condition monitoring),

• 10 CFR 50.65(a)(1) or (a)(2) classification and reclassification, and

• Appropriateness of performance criteria for SSCs/functions classified (a)(2) and/or appropriateness and adequacy of goals and corrective actions for SSCs/functions classified (a)(1).

b. Findings

No findings of significance were identified.

1R13 Maintenance Risk Assessments and Emergent Work Evaluation

a. Inspection Scope

For the five time periods listed below, the inspectors reviewed risk assessments and related activities to verify that the licensee performed adequate risk assessments and implemented appropriate risk-management actions when required by 10 CFR 50.65(a)(4). For emergent work, the inspectors also verified that any increase in risk was promptly assessed, and that appropriate risk-management actions were promptly implemented. Documents reviewed are listed in the Attachment. Those periods included the following:

• July 1 - July 3, including periods of Yellow risk during crane activities in the vicinity of the start-up transformer

• July 6 - July 10, including Yellow risk during crane activities in the vicinity of the start-up transformer and the steam driven auxiliary feedwater pump out of service for scheduled maintenance

• July 20 - July 24, including periods of Yellow risk during crane activities in the vicinity of the start-up transformer and B CCW heat exchanger out of service

• August 1 - August 7, including periods of Yellow risk during crane activities in the vicinity of the start-up transformer and an emergent issue that rendered the steam-driven auxiliary feedwater pump temporarily inoperable

• September 8 - September 11, including periods of Yellow risk during B emergency diesel generator surveillance testing and increased risk during preventive maintenance activities on the B auxiliary feedwater pump.

b. Findings

No findings of significance were identified.

1R15 Operability Evaluations

a. Inspection Scope

The inspectors reviewed the three operability determinations associated with the items listed below. The inspectors assessed the accuracy of the evaluations, the use and control of any necessary compensatory measures, and compliance with the Technical Specification (TS). The inspectors verified that the operability determinations were made as specified by Procedure OPS-NGGC-1305, Operability Determinations. The inspectors compared the justifications provided in the determinations to the requirements from the TS, the UFSAR, and associated design-basis documents to verify that operability was properly justified and the subject components or systems remained available, such that no unrecognized increase in risk occurred:

• AR 345707, A & B service water pumps in-service test criteria outside specified surveillance test range

• Work Request 391216, dedicated shutdown diesel generator south west intake louver did not open during testing

• AR 353252, component cooling water flow indication and alarm out of service for the A residual heat removal pump Documents reviewed are listed in the Attachment.

b. Findings

No findings of significance were identified.

1R18 Plant Modifications

a. Inspection Scope

The inspectors reviewed the temporary modification described in Procedure SPP-038, Installation, Operation, and Removal of Supplemental Cooling for the Containment Air Recirculation Cooling System HVH-1, 2, 3, & 4, Rev. 8, to verify that the modification did not affect the safety functions of important safety systems, and to verify that the modification satisfied the requirements of 10 CFR 50, Appendix B, Criterion III, Design Control. The inspectors also evaluated system operability, availability, configuration control, post-installation test activities, documentation updates, and operator awareness of the modifications.

Documents reviewed are listed in the Attachment.

b. Findings

No findings of significance were identified.

1R19 Post Maintenance Testing

a. Inspection Scope

For the seven post-maintenance tests listed below, the inspectors witnessed the test and/or reviewed the test data to verify that test results adequately demonstrated restoration of the affected safety functions described in the UFSAR and TS. Documents reviewed are listed in the Attachment.

The following tests were witnessed/reviewed:

Related Test Procedure Title Date Inspected Maintenance Activity OST-108-3 Comprehensive Flow Piping modification July 1 Test for Boric Acid including installation of Pump A an in-line flow meter Replacement of check OST-202 Steam Driven July 7 valve (AFW-13) and Auxiliary Feedwater inspection of motor System Component operated discharge Test valve AFW-V2-14B-MO OST-401-2 [Emergency Diesel Installation and July 14 Generator] B Slow removal of temperature Speed Start probes inside B emergency diesel generator control cabinets OST-258-2 [Residual Heat Test thermal overloads July 23 Removal] Valve on the breaker for Position Indicator Residual Heat Verification - Train B Removal heat exchanger outlet valve RHR-759B OST-258-1 [Residual Heat Test thermal overloads July 28 Removal] System on the breaker for Valve Test - Train A Residual Heat Removal pump suction valve RHR-752A LP-357 Steam Generator Replace NUS Isolator August 5 Level (Steam Flow) for steam flow FM-474 Channel 474 OST-101-3 Chemical Volume Motor replacement September 16 Control System (CVCS) Component Test Charging Pump C

The inspectors reviewed the following ARs associated with this area to verify that the licensee identified and implemented appropriate corrective actions:

• 327510, B emergency diesel generator fuel oil piping leak

• 322119, return to service testing of equipment important to safety was delayed resulting in increased unavailability

b. Findings

No findings of significance were identified.

1R22 Surveillance Testing

a. Inspection Scope

For the six surveillance tests listed below, the inspectors witnessed testing and/or reviewed the test data to verify that the systems, structures, and components involved in these tests satisfied the requirements described in the TS, the UFSAR, and applicable licensee procedures, and that the tests demonstrated that the SSCs were capable of performing their intended safety functions. Documents reviewed are listed in the

.

Test Procedure Title Date Inspected OST-401-1 [Emergency Diesel Generator] A Slow July 1 Speed Start OST-101-3* [Chemical Volume Control System] July 16 Component Test Charging Pump C OST-251-2 [Residual Heat Removal] Pump B and July 23 Components Test EST-010 Containment Personnel Airlock July 29 Leakage Test (Semiannual)

LP-357 Steam Generator Level (Steam Flow) August 5 Channel 474 OST-151-3 Safety Injection Pump C Test September 17

• This procedure included inservice testing requirements.

b. Findings

No findings of significance were identified.

Cornerstone: Emergency Preparedness

1EP6 Drill Evaluation

a. Inspection Scope

On September 14, 2009, the inspectors observed an emergency preparedness drill to verify licensee self-assessment of classification, notification, and protective action recommendation development in accordance with 10 CFR 50, Appendix E. The inspectors also attended the post-drill critique to verify that the licensee properly identified failures in classification, notification and protective action recommendation development activities.

b. Findings

No findings of significance were identified.

4OA1 Performance Indicator (PI) Verification

a. Inspection Scope

The inspectors verified the PIs identified below. For each PI, the inspectors verified the accuracy of the PI data that had been previously reported to the NRC by comparing those data to the actual data, as described below. The inspectors also compared the licensees basis in reporting each data element to the PI definitions and guidance contained in NEI 99-02, Regulatory Assessment Indicator Guideline, Rev. 5. In addition, the inspectors interviewed licensee personnel associated with collecting, evaluating, and distributing these data.

Initiating Events Cornerstone

• Unplanned Scrams

• Scrams with Loss of Heat Removal

• Unplanned Power Changes For the period from the first quarter of 2008 through the second quarter of 2009, the inspectors reviewed a selection of licensee event reports, operator log entries, daily reports (including the daily CR descriptions), monthly operating reports, and PI data sheets to verify that the licensee had accurately identified the number of scrams and unplanned power changes greater than 20 percent that occurred during the subject period. The inspectors compared those numbers to the numbers reported by the licensee for the PI. The inspectors also reviewed the accuracy of the number of critical hours reported, and the licensees basis for crediting normal heat removal capability for each of the reported reactor scrams.

Documents reviewed are listed in the Attachment.

b. Findings

No findings of significance were identified.

4OA2 Identification and Resolution of Problems

.1 Routine Reviews of ARs

To aid in the identification of repetitive equipment failures or specific human performance issues for followup, the inspectors performed frequent screenings of items entered into the Corrective Action Program (CAP). The review was accomplished by reviewing daily AR reports.

.2 Annual Sample Review

a. Inspection Scope

The inspectors selected ARs 301453, RHR-751 body inner surface damaged and 301508, RHR-751 guide rail welds cracked for a single sample review. The inspectors selected this issue because it relates specifically to the Mitigating Systems Cornerstone.

The inspectors reviewed the licensees response to verify:

• complete and accurate identification of the problem in a timely manner;

• evaluation and disposition of performance issues;

• evaluation and disposition of operability and reportability issues;

• consideration of extent of condition, generic implications, common cause, and previous occurrences;

• appropriate classification and prioritization of the problem;

• identification of root and contributing causes of the problem;

• identification of corrective actions which were appropriately focused to correct the problem; and

• completion of corrective actions in a timely manner.

The inspectors also reviewed this AR to verify compliance with the requirements of the CAP as delineated in Procedure CAP-NGGC-0200, Corrective Action Program, and 10 CFR 50, Appendix B. Documents reviewed are listed in the Attachment.

b. Observations and Findings

No findings of significance were identified.

4OA5 Other Activities

.1 Quarterly Resident Inspector Observations of Security Personnel and Activities

a. Inspection Scope

During the inspection period, the inspectors observed Security force personnel and activities to ensure that the activities were consistent with licensee security procedures and regulatory requirements relating to nuclear plant security. These observations took place during both normal and off-normal plant working hours.

These quarterly resident inspector observations of security force personnel and activities did not constitute any additional inspection samples. Rather, they were considered an integral part of the inspectors normal plant status review and inspection activities.

b. Findings

No findings of significance were indentified.

.2 Operation of an Independent Spent Fuel Storage Installation (ISFSI) (IP 60855.1)

a. Inspection Scope

The inspectors performed a walkdown of the two ISFSIs on site (reference dockets 72-3 and 72-60) and monitored the activities associated with the dry fuel storage campaign conducted August 22 through September 11. The inspectors also reviewed changes made to programs and procedures and their associated 10 CFR 72.48 screens and/or evaluations to verify that changes made were consistent with the license or Certificate of Compliance; reviewed records to verify that the licensee has recorded and maintained the location of each fuel assembly placed in the ISFSIs; and reviewed surveillance records to verify that daily surveillance requirements were performed as required by technical specifications. Documents reviewed are listed in the attachment.

b. Findings

No findings of significance were identified.

4OA6 Meetings, Including Exit

On October 15, 2009, the resident inspectors presented the inspection results to Mr.

Keith Jensen and other members of his staff. The inspectors confirmed that proprietary information was not provided or examined during the inspection.

ATTACHMENT:

SUPPLEMENTAL INFORMATION

KEY POINTS OF CONTACT

Licensee personnel

W. Farmer, Engineering Manager

K. Jensen, Maintenance Manager

K. Jones, Operations Manager

J. Lucas, Nuclear Assurance Manager

E. McCartney, Vice President

J. Rhodes, Radiation Protection Superintendent

S. Saunders, Plant General Manager

K. Smith, Training Manager

S. Wheeler, Outage & Scheduling Manager

B. White, Manager, Support Services - Nuclear

NRC personnel

R. Musser, Chief, Reactor Projects Branch 4, Division of Reactor Projects, Region II

LIST OF ITEMS OPENED, CLOSED, AND DISCUSSED

Opened

None

Closed

None Opened &

Closed

None

Discussed

None